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EP1936128A1 - Procédé et système pour la réduction d'émissions de CO2 dans un flux de combustion - Google Patents

Procédé et système pour la réduction d'émissions de CO2 dans un flux de combustion Download PDF

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Publication number
EP1936128A1
EP1936128A1 EP07122328A EP07122328A EP1936128A1 EP 1936128 A1 EP1936128 A1 EP 1936128A1 EP 07122328 A EP07122328 A EP 07122328A EP 07122328 A EP07122328 A EP 07122328A EP 1936128 A1 EP1936128 A1 EP 1936128A1
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EP
European Patent Office
Prior art keywords
exhaust stream
stream
gas turbine
turbine engine
engine assembly
Prior art date
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Granted
Application number
EP07122328A
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German (de)
English (en)
Other versions
EP1936128B1 (fr
Inventor
Matthias Finkenrath
Michael Adam Bartlett
Stephanie Marie-Noelle Hoffmann
Narendra Digamber Joshi
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General Electric Co
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General Electric Co
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Publication date
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Publication of EP1936128A1 publication Critical patent/EP1936128A1/fr
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    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
    • F01K23/00—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids
    • F01K23/02—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled
    • F01K23/06—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle
    • F01K23/10—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/22—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by diffusion
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/46—Removing components of defined structure
    • B01D53/62—Carbon oxides
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES 
    • F23J15/00—Arrangements of devices for treating smoke or fumes
    • F23J15/06—Arrangements of devices for treating smoke or fumes of coolers
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/50—Carbon oxides
    • B01D2257/504—Carbon dioxide
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES 
    • F23J2215/00—Preventing emissions
    • F23J2215/50—Carbon dioxide
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES 
    • F23J2219/00—Treatment devices
    • F23J2219/70—Condensing contaminants with coolers
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES 
    • F23J2900/00—Special arrangements for conducting or purifying combustion fumes; Treatment of fumes or ashes
    • F23J2900/15061—Deep cooling or freezing of flue gas rich of CO2 to deliver CO2-free emissions, or to deliver liquid CO2
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
    • Y02A50/00—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE in human health protection, e.g. against extreme weather
    • Y02A50/20—Air quality improvement or preservation, e.g. vehicle emission control or emission reduction by using catalytic converters
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02C—CAPTURE, STORAGE, SEQUESTRATION OR DISPOSAL OF GREENHOUSE GASES [GHG]
    • Y02C20/00—Capture or disposal of greenhouse gases
    • Y02C20/40—Capture or disposal of greenhouse gases of CO2
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E20/00—Combustion technologies with mitigation potential
    • Y02E20/16—Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E20/00—Combustion technologies with mitigation potential
    • Y02E20/30—Technologies for a more efficient combustion or heat usage
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E20/00—Combustion technologies with mitigation potential
    • Y02E20/32—Direct CO2 mitigation

Definitions

  • This application relates generally to combustion streams and, more particularly, to reducing CO 2 emissions in combustion streams.
  • the cost of CO 2 capture is generally estimated to represent three-fourths of the total cost of a carbon capture, storage, transport, and sequestration.
  • CO 2 removal technologies e.g., CO 2 removal technologies that can be retrofitted into existing power plants and the like.
  • a method for reducing emissions in a combustion stream comprises: producing power in a gas turbine engine assembly, wherein an exhaust stream exits the gas turbine engine assembly, compressing the exhaust stream; and separating CO 2 from the exhaust stream by passing the CO 2 through a membrane to produce a CO 2 product stream and a CO 2 lean exhaust stream.
  • a power plant comprises: a gas turbine engine assembly configured to produce power and an exhaust stream comprising CO 2 ; and a CO 2 separation unit configured to receive the exhaust stream.
  • the CO 2 separation unit comprises a unit compressor in flow communication with a CO 2 separation reactor inlet via a unit heat exchanger, and an unit expander in flow communication with the CO 2 separation reactor outlet via the unit heat exchanger.
  • a method for reducing emissions in a power plant comprises: producing power in a gas turbine engine assembly, wherein an exhaust stream exits the gas turbine engine assembly; changing an operating pressure of the exhaust stream; changing an operating temperature of the exhaust stream; passing CO 2 in the exhaust stream through a membrane in a CO 2 separation reactor to produce a CO 2 product stream and a CO 2 lean exhaust stream; changing a temperature of the CO 2 lean exhaust stream to produce a cooled exhaust stream; and cooling air entering the gas turbine engine assembly with the cooled exhaust stream.
  • a method for reducing emissions in a combustion stream comprises: combusting a gaseous stream to produce an exhaust stream comprising carbon dioxide, and separating CO 2 from the exhaust stream by passing CO 2 through a membrane to produce a CO 2 product stream and a CO 2 lean exhaust stream.
  • Carbon dioxide (CO 2 ) emissions from power plants are increasingly penalized by national and international regulations, such as the Kyoto protocol, and the EU Emission Trading Scheme. With increasing cost of emitting CO 2 , CO 2 emission reduction is becoming increasingly important for economic power generation.
  • CO 2 removal technologies concentrate on CO 2 clean up of the atmospheric flue gas stream of a power plant or other CO 2 generating processes, which results in very large, costly and energy intensive CO 2 removal units.
  • the present system comprises a CO 2 separation unit that has a compressor, expander, heat exchanger, and a CO 2 separation reactor.
  • the reactor which uses CO 2 membrane technology, can comprise both carbon monoxide (CO) conversion and CO 2 removal capabilities.
  • CO carbon monoxide
  • the present solution is easy to implement on all existing and future power plants, as no integration with the main power system is required.
  • still heat recovery from the main power system could be implemented, including heat recovery from the hot gas turbine exhaust gas, or a gas turbine intercooler (if available).
  • Figure 1 is a schematic illustration of an exemplary power plant 6 that includes a combustion process (e.g., exemplary gas turbine engine assembly 10).
  • a combustion process e.g., exemplary gas turbine engine assembly 10.
  • Possible other combustion processes can also, or alternatively, employed, such as a combustor, furnace, and other processes that produce a stream comprising CO 2 (e.g., governmentally regulated amounts of CO 2 )), such as coal-fired power plants, oil-fired boilers, cement or steel factories, and so forth.
  • CO 2 e.g., governmentally regulated amounts of CO 2
  • Gas turbine engine assembly 10 includes a core gas turbine engine 12 that includes compressor(s) (e.g., a high-pressure compressor 14 (e.g., that can compress the stream to pressures of greater than or equal to about 45 bar) and a low-pressure compressor 20 (e.g., that can compress up to about 5 bar)), combustor(s) 16, and turbine(s) (e.g., a high-pressure turbine 18 and a low-pressure turbine 22).
  • High-pressure compressor 14 and high-pressure turbine 18 are optionally coupled by a first shaft 24, and low-pressure compressor 20 can be coupled to an intermediate pressure turbine (not shown) by a second shaft 26.
  • low-pressure turbine 22 is coupled to a load, such as a generator 28 via a shaft 30.
  • core gas turbine engine 12 is an LMS100 available from General Electric Aircraft Engines, Cincinnati, Ohio.
  • the gas turbine engine assembly 10 can optionally include an intercooler 40 to facilitate reducing the temperature of the compressed airflow entering high-pressure compressor 14. More specifically, intercooler 40 is in flow communication between low-pressure compressor 20 and high-pressure compressor 14 such that airflow discharged from low-pressure compressor 20 is cooled prior to being supplied to high-pressure compressor 14.
  • intercooler 40 is a water-to-air heat exchanger that has a working fluid (not shown) flowing therethrough.
  • the working fluid can be raw water that is channeled from a body of water located proximate to power plant 8, such as a lake, for example.
  • intercooler 40 is an air-to-air heat exchanger that has a cooling airflow (not shown) flowing therethrough.
  • Power plant 6 also optionally includes a heat recovery steam generator (HRSG) 50 that is configured to receive the relatively hot exhaust stream discharged from the gas turbine engine assembly 10 and transfer this heat energy to a working fluid flowing through the HSRG 50 to generate steam which, in the exemplary embodiment, can be used to drive a steam turbine 52.
  • HRSG heat recovery steam generator
  • a condenser 54 can be located downstream from HSRG 50 to substantially remove the water vapor from the exhaust stream discharged from HSRG 50 by lowering the gas temperature.
  • a dehumidifier (not shown) can also be employed downstream of the HRSG 50 and upstream of the condenser 54, to facilitate water removal from the exhaust stream.
  • the dehumidifier can comprise a desiccant air drying system.
  • the power plant 6 further includes an exemplary CO 2 separation unit 32.
  • the CO 2 separation unit 32 comprises a second low-pressure compressor 60, an expander 62, and a shaft 64 used to couple second low-pressure compressor 60 to expander 62.
  • Expander can be a centrifugal or axial flow turbine through which a high-pressure gas is expanded to produce work that can be used to drive a compressor, such as low-pressure compressor 60.
  • Expander 62 also referred to as a turboexpander or expansion turbine
  • a prime mover 66 see Figure 2
  • an electric motor, a gas turbine, a reciprocating engine, or so forth via a shaft 68.
  • prime mover 66 is utilized to drive the low-pressure compressor 60, assisted by the expander 62, as will be discussed below.
  • desiccant air drying system(s) can be used in the CO 2 separation unit 32, e.g., downstream of the CO 2 separation reactor 80, downstream of the intercooler 34.
  • the power plant 8 can also include a second intercooler or heat exchanger 70 (see Figure 2 ) that is in flow communication with low-pressure compressor 60 and expander 62.
  • intercooler 70 is a water-to-air heat exchanger that has a working fluid (not shown) flowing therethrough.
  • the working fluid can be raw water that is channeled from a body of water located proximate to power plant 8.
  • the cool water may also be generated using a wet cooling tower, and/or intercooler 70 can be an air-to-air heat exchanger that has a cooling airflow (not shown) flowing therethrough.
  • the exhaust stream discharged from expander 62 can then be supplied to a third heat exchanger 72 to facilitate reducing the operational temperature of the inlet air supplied to gas turbine engine assembly 10, as will be discussed below.
  • gas turbine engine assembly 10 During operation, ambient air drawn into the gas turbine is channeled through heat exchanger 72 to facilitate reducing the operational temperature of the ambient air being supplied to gas turbine engine assembly 10.
  • Gas turbine engine assembly 10 is operated as known in the art, and as such, produces an exhaust stream having a temperature of about 600 degrees Fahrenheit (°F) (316 degrees Celsius (°C)) to about 1,300°F (704°C).
  • the exhaust stream discharged from gas turbine engine assembly 10 is channeled through HRSG 50 wherein a substantial portion of the heat energy from the exhaust stream is transferred to a Rankine cycle, with the working fluid channeled therethrough to generate steam that as discussed above, that can be utilized to drive steam turbine 52.
  • HSRG 50 facilitates reducing the operational temperature of the exhaust stream to a temperature that is about 75°F (24°C) and about 248°F (120°C). In the exemplary embodiment, HSRG 50 facilitates reducing the operational temperature of the exhaust stream to a temperature that is approximately 100°F (38°C).
  • the exhaust stream can be simply cooled without utilizing the heat rejected to useful purpose, and/or it can be linked to another process to provide heat in the form of steam or hot water.
  • the exhaust stream can also be channeled through additional heat exchangers (not shown) to further condense water from the exhaust stream, which water is then discharged through condenser 54, for example.
  • a fraction of the exhaust gas can optionally be recirculated back and to the main gas turbine engine assembly 10; e.g., about 30 vol% to about 70 vol% of the exhaust stream can be recycled to enter the gas turbine engine assembly with the air).
  • the mixing of the recirculated exhaust gas and the fresh air can take place up or downstream of optional heat exchanger 72.
  • Recirculating a fraction of the exhaust stream to the inlet of gas turbine engine assembly 10 increases the CO 2 concentration in the working fluid, thereby increasing the driving forces for the CO 2 separation in CO 2 separation reactor 80.
  • exhaust gas recirculation can help to lower other combustion emissions, such as lowering the formation of NOx.
  • Second low-pressure compressor 60 can be utilized to increase the operating pressure of the exhaust stream channeled therethrough to a pressure that is approximately four times greater than the operating pressure of the exhaust stream discharged from gas turbine engine assembly 10. Moreover, channeling the exhaust stream through the second low-pressure compressor causes the temperature of the exhaust stream to increase.
  • the exhaust stream discharged from second low-pressure compressor 60 is then optionally channeled through a second intercooler 70 to facilitate reducing the operational temperature of the exhaust stream, if advantageous for operating the CO 2 separation reactor 80 and/or the system.
  • second intercooler 70 facilitates reducing the operational temperature of the exhaust stream to a temperature that is about 100°F (38°C).
  • CO 2 separation reactor 80 can comprises various CO 2 separation processes such as CO 2 selective membrane technologies, sorption processes (adsorption and/or absorption), diaphragms, cryogenic processes, and so forth, as well as combinations comprising at least one of the foregoing processes.
  • the membranes can be sealed from the flow of the exhaust stream in any fashion that optionally enables a sweep gas to remove the CO 2 without entering the exhaust stream.
  • the CO 2 passes through walls of the membrane to an enclosed area on the other side of the membrane, while the exhaust stream continues through the reactor.
  • the sweep gas enters the enclosed area, passing by the membranes and removing the CO 2 that has pass through the walls of the membranes.
  • the sweep gas optionally carries the CO 2 out of the reactor through a separate exit than the remainder of the exhaust stream.
  • the membrane(s) are CO 2 selective and thus continuously remove the CO 2 produced, including CO 2 which is optionally produced from CO in catalyst portion(s), which can be added to the membrane if required.
  • the membrane can comprise any membrane material that is stable at the operating conditions and has the required CO 2 permeability and selectivity at the operating conditions.
  • Possible membrane materials that are selective for CO 2 include certain inorganic and polymer materials, as well as combinations comprising at least one of these materials.
  • Inorganic materials include microporous carbon, microporous silica, microporous titanosilicate, microporous mixed oxide, and zeolite materials, as well as combinations comprising at least one of these materials.
  • mechanisms for CO 2 selectivity in microporous materials include surface diffusion and capillary condensation.
  • a material that has an affinity for CO 2 relative to other gases in a stream will show a preferred adsorption and surface diffusion of CO 2 .
  • the presence of the adsorbed CO 2 molecules, through capillary condensation will effectively block the pore from the more weakly adsorbing gases, thereby hindering their transport.
  • the gas selectivity through the membrane is determined by the relative contributions of Knudsen flow and surface diffusion to the total transport of gas. For example, to achieve CO 2 selectivity, surface diffusion must make a significant contribution to the total CO 2 transport. The rate of surface diffusion depends on the amount of CO 2 adsorbed and its relative mobility.
  • the surface diffusivity of a gas on a material can be estimated from the heat of adsorption. Since the diffusivity varies exponentially with the negative of the heat of adsorption, materials with lower heats of adsorption exhibit higher surface diffusivity. Physically, this means that materials suitable for functional materials have a greater affinity for CO 2 than for other gases in the stream, but the affinity for CO 2 is not so great that the CO 2 binds to the surface without transporting through the pore channel. Low heats of adsorption correspond to weakly bonded CO 2 , which favors high diffusivities.
  • the ceramic comprises a material such as SiO 2 , BaTiO 3 , BaZrO 3 , LaFeO 3 , as well as combinations comprising at least one of these materials. These oxides theoretically show substantially high mobility for surface diffusion of CO 2 and hence can provide the required permeability.
  • the membrane often comprises a separation layer that is disposed upon a support layer.
  • the porous support can comprise a material that is different from the separation layer.
  • Support materials for asymmetric inorganic membranes include porous alumina, titania, cordierite, carbon, silica glass (e.g., Vycor®), and metals, as well as combinations comprising at least one of these materials.
  • Porous metal support layers include ferrous materials, nickel materials, and combinations comprising at least one of these materials, such as stainless steel, iron-based alloys, and nickel-based alloys.
  • Polymeric membranes can be disposed on polymeric or inorganic supports.
  • Membranes can include polymeric materials such as polyethers and polyether blends and hybrid membranes such as silanized gamma-alumina membranes.
  • Silanes such as 2-acetoxyethyl, 2-carbomethoxyethyl and 3-aminopropyl, can be integrated with ceramic membranes to achieve selective CO 2 transport.
  • the CO 2 lean exhaust stream discharged from the CO 2 separation reactor 80 can optionally expanded through expander 62 which extracts work from the pressurized exhaust gases to drive low-pressure compressor 60, thus reducing the temperature of the exhaust stream substantially.
  • the temperature of the exhaust stream discharged from expander 62 is about 30°F (-1°C) to about -30°F (-34°C).
  • the temperature of the exhaust stream discharged from expander 62 is approximately -20°F.
  • the relatively cooler exhaust stream can then be channeled through heat exchanger 72 to facilitate cooling the inlet air stream, and to facilitate increasing the air density of the airflow that is channeled to gas turbine engine assembly 10, thus increasing the efficiency and power output of the core gas turbine engine 12.
  • the reduction in the inlet temperature of the air flow to the gas turbine increases its mass flow and efficiency reducing the economic impact of the CO 2 separation process.
  • FIG 3 is a schematic illustration of another exemplary power plant 100.
  • Power plant 100 is substantially similar to power plant 8, shown in Figure 2 .
  • power plant 100 does not include heat exchanger 72, rather the relatively cool dry exhaust stream discharged from expander 62 is separated into a first air stream portion 110 that is discharged directly into the inlet of gas turbine engine assembly 10 and a second air stream portion 112 that is channeled through a heat exchanger 120 that is positioned upstream from second low-pressure compressor.
  • moisture can be removed from the first air stream portion 110 and/or the inlet airflow utilizing desiccant air drying system(s).
  • the first air stream 110 is channeled directly into the inlet air stream supplied to gas turbine engine assembly 12. More specifically, any moisture still entrained within incoming fresh air stream is condensed into relatively small or microscopic droplets which produces a fine fog or mist, when mixed with the air stream 110.
  • the fog or mist is then channeled into low-pressure compressor 20 wherein the droplets evaporate to facilitate reducing the operational temperature of the airflow supplied to core gas turbine engine 12.
  • the temperature of the airflow channeled into the core gas turbine engine 12 is decreased, thus reducing the work required in the compression process and increasing the overall efficiency of the gas turbine engine assembly 10.
  • the oxygen content of the stream 110 is reduced due to the combustion process in the gas turbine 10.
  • the mixing of this stream with fresh air results in a net reduction of oxygen content of the combustion air in combustor 16 facilitating reduction of NOx formation in the combustor.
  • the second air stream portion 112 can be channeled through heat exchanger 120 to facilitate removing heat energy from the exhaust stream channeled into second low-pressure compressor 60 and to facilitate condensing and removing water entrained in the exhaust air stream prior to the exhaust air stream entering second low-pressure compressor 60.
  • the method includes increasing separating substantially all the CO 2 entrained within the exhaust gas using a CO 2 separation reactor where CO in the exhaust stream is converted to CO 2 , and the CO 2 is removed through CO 2 selective membranes, to produce a CO 2 lean stream.
  • the CO 2 lean stream can be exhausted and/or can be recycled to the gas turbine engine assembly. This can be accomplished by using the exhaust stream from the gas turbine engine assembly without increasing the pressure and/or decreasing the temperature.
  • the exhaust stream can be treated in the CO 2 separation reactor at a temperature of about 250°C to about 500°C (e.g., about 300°C to about 450°C), and a pressure of about less than 5 bar (0.5 megapascals (MPa); e.g., more particularly, about 1 bar to about 4 bar (about 0.1 MPa to about 0.4 MPa)).
  • the CO 2 lean stream from the CO 2 separation reactor can pass directly to the expander (e.g., turbine), e.g., without passing through a heat exchanger. This process, even with compressing to about 5 bars, can remove greater than or equal to about 80 vol% of the CO 2 in the exhaust stream, or, more specifically, about 80 vol% to about 90 vol% of the CO 2 in the exhaust stream can be removed.
  • Additional advantages include the fact that there is no need of integration of the compressor-expander unit into the main power system; the present system is capable of being retro-fitted into existing systems with CO 2 capture.
  • the retro-fitability is not limited to power cycles based on gas turbines, but can be applied to any combustion process generating CO 2 .
  • the heat exchanger can be integrated with the main power system, if advantageous. This could lead to a reduction of the power requirement needed to drive the compressor-expander unit, or even help to make it energy self-sustainable. This then reduces or eliminates the need for having a (large) prime mover or motor.
  • optional re-heat within the compressor-expander unit by a heat exchanger or similar can be used and/or other heat recovery strategies and humidification can be used advantageously to minimize the power demand within the compressor-expander unit.
  • Humidification of the working fluid after compression can be applied to utilize process heat and increase the mass flow of the fluid, thereby increasing the overall efficiency of the cycle and leading to an increased power generation in the expander section when expanding the CO 2 lean working fluid.
  • the pressurized working fluid in the compressor-expander can optionally be cooled down, and can be expanded to atmospheric pressure after the CO 2 removal.
  • the cool (very low or even sub-zero temperatures) expanded working fluid can be used for inlet chilling of the inlet flow into the main gas turbine.
  • Ranges disclosed herein are inclusive and combinable (e.g., ranges of "up to about 25 wt%, or, more specifically, about 5 wt% to about 20 wt%", is inclusive of the endpoints and all intermediate values of the ranges of "about 5 wt% to about 25 wt%,” etc.).
  • “Combination” is inclusive of blends, mixtures, alloys, reaction products, and the like.
  • first,” “second,” and the like, herein do not denote any order, quantity, or importance, but rather are used to distinguish one element from another, and the terms “a” and “an” herein do not denote a limitation of quantity, but rather denote the presence of at least one of the referenced item.

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  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Combustion & Propulsion (AREA)
  • General Engineering & Computer Science (AREA)
  • Analytical Chemistry (AREA)
  • General Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Mechanical Engineering (AREA)
  • Environmental & Geological Engineering (AREA)
  • Health & Medical Sciences (AREA)
  • Biomedical Technology (AREA)
  • Separation Using Semi-Permeable Membranes (AREA)
  • Treating Waste Gases (AREA)
  • Engine Equipment That Uses Special Cycles (AREA)
  • Exhaust Gas After Treatment (AREA)
EP07122328A 2006-12-11 2007-12-05 Procédé et système pour la réduction d'émissions de CO2 dans un flux de combustion Active EP1936128B1 (fr)

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
US11/609,092 US7966829B2 (en) 2006-12-11 2006-12-11 Method and system for reducing CO2 emissions in a combustion stream

Publications (2)

Publication Number Publication Date
EP1936128A1 true EP1936128A1 (fr) 2008-06-25
EP1936128B1 EP1936128B1 (fr) 2013-03-20

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EP07122328A Active EP1936128B1 (fr) 2006-12-11 2007-12-05 Procédé et système pour la réduction d'émissions de CO2 dans un flux de combustion

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US (1) US7966829B2 (fr)
EP (1) EP1936128B1 (fr)
JP (1) JP5086049B2 (fr)
CN (1) CN101201171B (fr)
RU (1) RU2466775C2 (fr)

Cited By (6)

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US20080134660A1 (en) 2008-06-12
RU2466775C2 (ru) 2012-11-20
US7966829B2 (en) 2011-06-28
JP5086049B2 (ja) 2012-11-28
RU2007145805A (ru) 2009-06-20

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